EP2065553B1 - Système et procédé pour forer des trous de forage latéraux - Google Patents
Système et procédé pour forer des trous de forage latéraux Download PDFInfo
- Publication number
- EP2065553B1 EP2065553B1 EP07122050.3A EP07122050A EP2065553B1 EP 2065553 B1 EP2065553 B1 EP 2065553B1 EP 07122050 A EP07122050 A EP 07122050A EP 2065553 B1 EP2065553 B1 EP 2065553B1
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- European Patent Office
- Prior art keywords
- drilling
- unit
- borehole
- liner
- casing
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Images
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/0035—Apparatus or methods for multilateral well technology, e.g. for the completion of or workover on wells with one or more lateral branches
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
- E21B23/01—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B4/00—Drives for drilling, used in the borehole
- E21B4/02—Fluid rotary type drives
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/0035—Apparatus or methods for multilateral well technology, e.g. for the completion of or workover on wells with one or more lateral branches
- E21B41/0042—Apparatus or methods for multilateral well technology, e.g. for the completion of or workover on wells with one or more lateral branches characterised by sealing the junction between a lateral and a main bore
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
- E21B43/10—Setting of casings, screens, liners or the like in wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B7/00—Special methods or apparatus for drilling
- E21B7/04—Directional drilling
- E21B7/046—Directional drilling horizontal drilling
Definitions
- This invention relates to systems and methods for drilling lateral boreholes from a main borehole.
- it relates to such systems and methods which use a flow of fluid along a tubular conduit to provide a power source for the various operations.
- Lateral wells or drainholes are boreholes drilled out from a main well or borehole to improve communication with the formation.
- Conventional techniques for forming a lateral drainhole comprise the following multiple trips and steps:
- US 6,167,968B1 and US 5,392,858 disclose an apparatus for drilling holes in the steel casing of an oil or gas well, and drilling into the surrounding formations, including a number of components controlled by hydraulic fluid.
- This tool is available commercially under the trade name PeneDRILL by Penetrators Canada Inc.
- the tool is controlled and powered by fluid circulation from surface. It is capable to mill a 26mm hole in the production casing and to drill a 17mm hole in formation rock up to 2 meters in length.
- the tool contains two different drilling systems, one for metal casing and the other for formation rock.
- the tool is operable in the casing from 114mm to 178mm OD and is capable of four to eight tunnels per run.
- the CHDT tool of Schlumberger comprises a downhole tool which uses a single drill bit and stem for casing milling and formation drilling. Further details are disclosed in US 5,746,279 , US 5,692,565 , US 5,779,085 (and US 5,195,588 ) and US 5,687,806 .
- the CHDT (Cased Hole Dynamics Tester) tool is a 108mm diameter tool and is capable to drill a 7mm diameter hole with 150mm maximum penetration.
- the SCDT (Sidewall CoreDriller Tool), also of Schlumberger, is another similar tool with a 137mm tool diameter. This tool cuts a cylindrical core with dimensions of 23mm OD and 50mm long from formation with up to 50 cores per trip. Neither the CHDT, SCDT or PeneDRILL tools are capable of installing liners or sealing them to casing in the main borehole.
- US 6,260,623 discloses an apparatus and a method for utilizing a flexible tubing string to form and isolate a lateral entrance opening to a lateral bore hole from a main borehole.
- US 5,074,366 describes a method and an apparatus for simultaneously drilling and casing a wellbore.
- the apparatus comprises an outer conduit string containing an inner drill string carrying a bit capable of drilling a wellbore with a greater diameter than the outer string.
- the drill string may be adapted to drill a nonlinear wellbore by offsetting the drill bit from the longitudinal axis of the outer string, and the drill bit is preferably retractable to permit withdrawal of the drill string after the wellbore completed, leaving the outer string of casing or liner in place.
- US 5,715891 discloses a method for isolating each perforated or drainhole completion with the primary wellbore, for providing flow control means for each completion to permit selective testing simulation, production, or abandonment, and for facilitating selective re-entry into any cased drainhole for conducting additional drilling, completion, or remedial work.
- US 6,220,372 describes an apparatus for drilling lateral drainholes from a well casing with a flexible shaft having a bit at lower end to drill the drainholes in perpendicular to the main hole.
- US 6,263,984 describes a nozzle jet drill bits for drilling drainholes from a wellbore through a 114mm or larger casing.
- US 4,787,465 discloses a similar method and technique involving a hydraulic drilling apparatus and method suitable for use in a variety of applications including the drilling of deep holes for oil and gas wells and the drilling of vertical, horizontal or slanted holes, drilling through both consolidated and unconsolidated formations, and cutting and removing core samples.
- US 6,332,498 describes a completion method for drainholes.
- This invention includes a sleeve which can be positioned to give access to a window opening of the casing section in which the main casing is sealed from the liner section of a deviated wellbore to provide a hydraulic seal against passage of fluids from outside the casing of the wellbore into the main casing.
- US 6,648,068 describes a side tracking system including a window mill with a full-diameter cutting surface and a reduced diameter tapered cutting surface.
- US 6,662,876 describes an apparatus and a method for expanding tubulars in a wellbore.
- US 4,714,117 describes a method for completing a drainhole with casing, but without conventional cementing of the casing wherein in the drainhole portion of the wellbore a casing string composed of alternating casing subs and external casing packer subs is employed.
- US 4,402,551 describes a method and equipment to form horizontal cased and perforated drainholes for an underground, in-situ leach mining operation.
- SEL Slotted expandable liner
- SEC solid expandable casing
- This invention addresses these problems by using fluid flow as the power source and incorporating all functions in a single tool.
- One aspect of this invention provides a drilling system for drilling a lateral borehole from a main, borehole, comprising:
- the drilling unit By using the power available from the fluid flow from the surface, it is possible for the drilling unit to have the ability to drill lateral boreholes of the desired dimensions and, where appropriate, install liners and seal the liners to casing in the main borehole. Also, all functional sections can be provided in a single tool.
- the tubular conduit comprises drill string or coiled tubing.
- the power conversion unit operates to convert the flow of fluid from the conduit into electrical or hydraulic power.
- the drilling unit can comprise a rotary drilling head including a drill bit and a power unit to provide torque, weight on bit and/or axial movement of the bit.
- the drilling unit can also include sensors for measuring torque, weight and/or displacement.
- the drilling unit typically comprises a weight on bit transmission system which comprises a driven drill stem, a fluid pressure drop across the bit or a fluid jet arrangement.
- One embodiment of the drilling unit comprises a torque transfer system including a fluid-driven turbine for rotating the bit.
- Alternative forms for the drilling apparatus include an abrasive water-jet drilling unit, a hammer drilling unit, an ultrasonic drilling unit, a rotating ultrasonic drilling unit or a laser drilling unit.
- the drill can be string stored within the drilling unit and advanced from the drilling unit as drilling of the lateral borehole progresses.
- the drill string can also comprise the liner.
- the drill string is formed from at least one flexible or compliant element.
- the drill string is stored in a segmented form in the drilling unit which is operable to join the drill string segments end to end to form the drill string.
- the drilling unit can comprise either a single system for drilling (or milling) through both casing and the formation around the main borehole, or a first drilling sub-system for drilling though casing surrounding the main borehole; and a second, separate drilling sub-system for drilling into the formation surrounding the main borehole to form the lateral borehole.
- the liner unit is separate from the drilling apparatus and includes a separate liner that can be installed in the lateral borehole.
- the liner can be formed from at least one flexible or compliant element. It can also be stored in a segmented form in the drilling unit which is operable to join the liner segments end to end to form the liner.
- the drilling assembly also comprises means to seal the liner to a casing in the main borehole after deployment.
- the means to seal the liner to the casing comprises a swage piece that is forced into contact with the liner to seal it to the casing.
- the means to seal the liner to the casing can comprise means to expand the liner into contact with the casing, or a shaped formation on the end of the liner that can be forced into sealing engagement with the casing.
- a telemetry unit can be included, if required, the telemetry unit allowing downhole data to be transmitted to the surface of the main borehole and by which commands from the surface of the main borehole can be sent to the drilling assembly.
- the claimed system comprises a navigation unit including a plurality of sensors, which can be a magnetometer, an inclinometer, a gyro sensor and/or a casing collar locator to assist in positioning the assembly in the main borehole.
- Another aspect of the invention provides a method of drilling a lateral borehole from a main borehole using a drilling system as claimed in any preceding claim, comprising:
- the method further comprises:
- the method according to the invention can be used for enhancing the productivity of an existing producing well, or for in situ sampling and or measurements of the formation around the well.
- Figure 1 shows a schematic view of a tool according to an embodiment of the invention in a cased borehole
- This invention provides a drainhole construction and completion system, which can be capable of drilling a reasonably long lateral hole (25-38mm diameter, 2-10m long) perpendicular to the main well (which may be cased or open hole) and to placing a completion liner. Both drilling of the lateral hole and installation of the completion liner can be conducted with a single trip.
- the present invention provides a system capable of three major operating functions:
- One embodiment of a system according to the invention comprises a downhole tool with seven different modules shown in Figure 1 .
- a tubular conveyance 10 such as drill pipe or coiled tubing, is used to convey the tool inside a mail borehole 12 lined with steel casing and cement 14 in the conventional manner.
- the tool comprises a power conversion module 16, a telemetry module 18, a navigation module 20, a drilling power module 22, a liner carrier module 24, a drilling and sensor module 26 and an anchoring module 28.
- the function of each module is described in more detail below.
- the power conversion module 16 is used to convert fluid flow into a power source that is useable by the rest of the tool. Fluid is pumped from the surface through the drill pipes or CT 10 from the surface in the conventional manner. This flow is converted to electrical and/or hydraulic power in this section.
- the module includes a turbine that is driven by the fluid flow and is connected to a generator and/or a hydraulic pump. The flow of drilling fluid from the surface has the ability to provide substantially more power that would normally be available via wireline or a hydraulic line from the surface.
- the telemetry module 18 allows downhole data to be transmitted to surface (Uplink) or surface commands to be sent to the downhole tool (Downlink).
- a wireline cable is present as well as the drill string or CT
- a conventional wireline telemetry module can be used.
- a 'mud pulse' telemetry system (such as are used in while drilling applications such as MWD and LWD), e.g. the PowerPulse and SlimPulse systems of Schlumberger, can be used to perform the equivalent function using a mud telemetry system.
- the navigation module 20 includes navigation sensors such as magnetometers, inclinometers, gyros (such as are typically used for direction and inclination (D&I) modules in conventional downhole tools, whether for drilling or logging), and a casing collar locator (CCL) such as is commonly used in cased hole logging tools. These sensors provide the actual position of the tool in the well and allow the tool to be navigated to the desired depth and orientation accurately in the well 12. The data recorded by the navigation module are transmitted to the surface via the telemetry module where they are used to control positioning of the tool in the main borehole.
- D&I direction and inclination
- CCL casing collar locator
- the drilling power module 22 is responsible for converting the electrical and/or hydraulic power output from the power conversion module 16 into an appropriate form for use in a drilling and controlling the application of this power.
- a motor e.g. an electric or hydraulic motor
- axial actuators e.g. hydraulic rams, worm drives, etc.
- Monitoring sensors such as displacement sensors, torque sensors and weight sensors for drilling can also be provided to closely monitor the drainhole drilling process.
- a long drill stem and completion liner or multiple drill stems and completion liners are stored in the liner carrier module 24 for deployment into the drainhole.
- the drilling and sensor module 26 provides drilling mechanisms including torque, rotation, weight on bit, axial advancement, etc.
- This module can also include a protrusion piston to swage a completion liner at the casing 14 of the main borehole 12.
- Sensors, such as pressure sensors for monitoring reservoir pressures can also be provided in this module.
- the anchor module 28 includes controllable anchor devices which are operable to lock the tool in place while drilling the drainhole.
- the system of Figure 1 can accomplish drainhole construction with a single trip.
- the major functional steps are:
- Step 1 - Conveyance The tool is conveyed to the location of interest by the tubular conveyance as is shown in Figure 1 .
- Step 2 - Positioning Data from the navigation module sensors 20 (D&!, CCL) are communicated via the telemetry module 18 to the surface and are used by the operator to position the tool at the correct depth in the main borehole 12 with the correct orientation to allow drilling in the correct direction.
- Step 3 - Anchoring Once the tool is in position, the anchors 30 are deployed from the anchor module 28 to hold the tool in position in the casing 14 as is shown in Figure 2 .
- Step 4 - Drilling Once the tool is anchored in position, the drilling mechanism 32 is deployed from the drilling and sensor module 26 to drill through the casing 14 and into the formation around the main borehole 12 (see Figure 2 ).
- the preferred drilling mechanism comprises a rotary drilling technique in which torque, rotation and thrust force (WOB) needed for drilling are transmitted though a rotating drill stem to a drill bit.
- WOB torque, rotation and thrust force
- WOB can be created using different techniques.
- a system using a pressure drop across the drill bit is one other applicable method.
- Figure 3 shows a suitable dual-tube system 34, which allows flowing a fluid through the annular space 36 between an outer and an inner tube 38, 40 and flushing debris through the inner tube 40 as is found in ejector drilling, would create a thrust force pushing the bit against a formation rock.
- This system has the advantage that WOB is created locally near the bit and so there is no risk of buckling of a long drill stem.
- a system using a fluid jet technique is another potential WOB method.
- the fluid jet is ejected backwards (i.e. uphole) allowing propellant of the bit forward as well as lubricating the bit through nozzles.
- the circulation fluid is partially used to propel the bit and to create WOB.
- While torque and rotation are typically provided at the drill bit by rotating the drill stem, other techniques are possible.
- a hydraulic rotating motor like a turbine motor near the bit could generate sufficient rotation and torque to drive the bit during drilling.
- the axial flow of hydraulic fluid is converted to rotating motion with vanes, and the rotating motion is transmitted to the bit by a suitable mechanical transmission system.
- the similar technique is widely used in downhole tools converting from the fluid flow to electrical power through a turbine and alternator module.
- Step 5 - Deployment of Liner The most suitable method for deployment of a completion liner is while drilling rather than placing the liner in a separate operation.
- a segmented drill stem with the segments connected together in a chain-like arrangement can satisfy both the drill stem and completion liner functions.
- Figure 4 shows one embodiment of a drill stem segment suitable for this use (a pair of connected segments are shown).
- the segment 42a, 42b has a double-tube structure comprising an inner tube 44 and an outer tube 46 and a quick-connect feature comprising pegs 48 at one end of a segment which engage in corresponding J-slots 50 in the adjacent end of the next segment.
- the segments are deployed horizontally one by one as is shown in Figure 5-7 .
- Torque and WOB are applied to the first segment 42x to drive the drill bit radially out of the tool 10 until the end of the segment 42x reaches the edge of the tool 10.
- the drive system is disengaged and withdrawn ( Figure 5 ).
- a second segment 42y is withdrawn from a storage cassette or the like and placed behind the first segment 42x ( Figure 6 ).
- the drive system then engages in the J-slots at the end of the second segment 42y and advances it to engage the first segment 42x, the pegs on the second segment engaging in the J-slots of the first segment 42y ( Figure 7 ).
- torque and WOB can be applied to the drill bit via the two segments.
- this process can be repeated with multiple segments being connected to each other to build the single drill stem and completion liner.
- it is not necessary to be able to direct the drill string around an ultra-short radius curve.
- the double-tube structure allows fluid circulation; the fluid flows through the inner tube 44 towards the drill bit and it returns through the annular space between the inner and outer tubes 44, 46.
- FIG. 8 Other embodiments of the invention may employ a single, flexible drill stem 52 to comply with an ultra-short radius formed by a kick-off guide 54 (see Figure 8 ).
- a shaft must be able to transmit drilling power (TOR, WOB) as well as be able to flex.
- WOB drilling power
- One such shaft flexible shaft is built several layers of wires 56 wound on a mandrel 58 (see Figure 9 ).
- Such shafts are widely used to transmit rotary power along a curved path in equipment such as lawn trimmers, powered car seats, sunroof drive mechanisms, robots, etc.
- the flexible drill stem can be built by winding the wires on a hollow mandrel, which allows a fluid flow.
- a flexible and pre-perforated completion liner with near hole-diameter can be deployed and placed in a separate operation.
- a compliant drill stem which contains multiple universal joint functions is another option (for example, a drill stem of the type disclosed in WO 2004/113667 ).
- a suitable configuration has a double-tube structure similar to that of the segmented drill stem described above.
- the external tube has a number of circumferential slots and can behave as completion liner after drilling a hole (see Figure 10 ).
- a conventional flexible tube would be used for the inner tube for the fluid circulation (see Figure 11 ).
- the diameter of the liner should be slightly smaller than the drilled hole to facilitate deployment.
- An expandable and flexible completion liner using a technique of a self-propagating expandable screen, a pre-sprung screen, or an expandable screen is another option.
- the expandable liner is deployed with an expansion mandrel and it is activated or inflated by pulling or pushing the expansion mandrel mechanically.
- Step 6 Sealing of Completion: Once the liner has been placed in the drainhole, it is necessary to seal it to the casing at the main borehole.
- the sealing technique used will depend in part on the liner design and deployment method.
- a mechanical swaging technique is one that may be particularly applicable for the segmented drill stem described above and is claimed.
- a hollow sealing piece 60 with a wedge shape at the end is pushed into a space between the casing 14 and the liner 62 (see Figures 12 and 13 ) with a swaging piston 64.
- the last segment can be specially prepared to make a seal at casing 14.
- a ductile material such as a rubber or plastic ring 66 is mounted on the last segment 68 (see Figure 14 ).
- a mandrel piston 70 pushes and expands a portion of the last segment intersecting the casing wall (similar to expansion of a conventional expandable tubular).
- the rubber or plastic ring on the segment is also expanded with the body, and seals at the casing 14 (see Figure 15 ).
- a sealing feature can be integrated into the completion liner.
- a tapered and swaging feature 72 is provided at the end of the liner 74 (see Figure 16 ). The feature 72 is pushed into the drainhole by a piston 76 and seals by permanently deforming the sealing feature 72 at the casing 14 (see Figure 17 ).
- a tapered and self-tapping feature can be integrated into the completion liner.
- the liner is simply pushed into the hole until the sealing feature reaches the casing. It is then pushed and rotated to tap into the casing (similar to a self-tapping pipe plug) and seals at the casing.
- Step 7 - Retracting swaging and anchoring devices Any swaging tools used to seal the liner at the casing are pulled back, and the anchor devices are retracted to free the tool (see Figure 18 ).
- Step 8 - Move to next location or orientation: Once the anchors are released, the tool is ready to move and or re-orient to the next target in essentially the same operation as Step 1 above.
- Steps 1-4 described above in relation to cased hole operation apply in open hole also.
- Step 5' - retrieve drill string The drill stem is simply pulled back into the tool. Depending on applications and purposes, a completion liner may need to set in place. If so, similar operations described in the step 5 of Cased hole will be needed.
- Step 6 is not performed in the open hole case and steps 7 and 8 are essentially the same as described above.
- ultrasonic drilling and rotating ultrasonic drilling which has previously been used to machine very hard materials is possibly applicable in certain circumstances.
- EDM Electro Discharge Machining
- ultrasonic machining is a potential solution.
- Ultrasonic machining techniques can be an optional drilling method for hard and consolidated formations.
- a critical problem in a deep hole drilling is buckling of the long drill stem, as is mentioned above.
- the traditional method used to avoid this is to use stabilizers and guides with an external diameter close to the hole diameter at various locations along the drill stem.
- the present invention may require a flexible and elastic drill stem to accommodate an ultra-short radius making the use of such solutions difficult.
- One of the alternative solutions is a 'self-propelled' drill bit.
- a waterjet ejection technique or a differential pressure technique across the bit can create WOB near the drill bit.
- Torque transmission through a long flexible drill stem can be undesirable.
- the use of local torque generation near the bit will eliminate this problem.
- the invention is based on the use of fluid flow to provide power, it is possible for this fluid flow to be converted to rotating motion (torque) near the bit by using a hydraulic actuator.
- the present invention has a number of potential applications and would address three different areas:
- Minimization of pore pressure drop A significant pore pressure drop from virgin reservoir to wellbore restricts productivity of oil. The pressure drawdown particularly occurs across skin close to the vicinity of wellbore, which is a zone of permeability impairment due to filtration of the drilling fluid. This is a potential issue for the oil recovery. The system described above can potentially address this issue by constructing a reasonably long lateral hole far exceeding the damaged zone, which will permit minimization the pore pressure drop and result in a more effective oil recovery.
- Coning control In the pay zone, the water level rises due to the production of oil, and water may encroach into the oil reservoir resulting in unproductive oil recovery. This water encroachment does not occur homogeneously and uniformly. It tends to progress adjacent to wellbore first. This problem can be more controllable by using two lateral completions, one in oil layer and the other in water layer, which the system according to the invention is capable of performing. This well structure can behave as in-situ water injection to enhance the oil productivity and to allow a broader rising water-front.
- Oil recovery from a thin hydrocarbon reservoir The existing drainhole drilling technique is difficult and risky for a thin hydrocarbon reservoirs because of the entry curve from the main well to the lateral drainhole in the drilling trajectory.
- the system according to the invention addresses this issue by drilling the drainhole substantially perpendicular to the main wellbore.
- the drilling plan can be very simple since there is essentially no entry curve in the drilling trajectory.
- Clean and non-damaging perforating channels The conventional explosive perforation technique has a risk of casing, cement or/and formation damage due to impaction of the very fast jet. A zone of the formation compaction, providing an additional skin, also appears adjacent to the perforated tunnels.
- the system according to the invention helps eliminate such risks and impairments since the hole is drilled while flushing cuttings and debris.
- Loose formation grains and fine particles such as clays may be produced along with oil, gas and water from unconsolidated reservoir when the induced dragging forces of th flow overcome the formation's restraining forces.
- There are already several passive-control to address this problem such as
- Sand screen and Proppant (gravel) packer would address this issue in a more active manner by constructing a high conductance conduit with the lateral completion (large and thick artificial fracture), avoiding the destructive pressure gradient near the wellbore resulting in lower dragging forces.
- Pre-fracturing treatment in consolidated formation Fracturing of the consolidated and hard formations is a challenge because of a stable high hoop stress and excess perforating friction pressures. Unbalancing and destabilization of the wellbore stress pattern could reduce the pressures at which fracturing occurs. Several lateral holes would break and unbalance the high hoop stress, leading to a more effective fracturing operation
- Acidizing treatment is used to dissolve either the formation rock or materials, natural or induced, within the pore pressure spaces of the rock. It is also used to remove damaging materials induced by drilling or completion fluids or by production practice. However, strong chemicals are used in the acidizing services and their disposal is always problems. Sufficiently deep drainholes constructed by the new tool would exceed the contaminated and damaged zone and may eliminate costly and non-safety acidizing operations.
- a rock has high permeability if oil, gas, or water can flow easily through existing channels and low permeability if the connecting channels are very small and fluid flow is restricted.
- drilling fluids may enter the flow channels and later impair flow into the wellbore.
- the flow channels may not permit enough flow into the wellbore.
- the well may not be commercial because fluid can not flow into the wellbore fast enough. It then becomes necessary to create an artificial channel that will increase the ability of the reservoir rock to conduct fluid into the wellbore. Hydraulic fracturing can often create such channels. Artificial channels created from the large and deep drainholes constructed by the new tool would permit more effective and spatial fractures.
- In-situ measurements at remote place Various measurements such as pressure and electrical resistivity can be carried out by installing appropriate sensors in the drainhole where it is isolated from the main wellbore. The measurements would not be disturbed by events in the main wellbore. A pore pressure measurement at the end of the drainhole would provide more accurate information to construct both a static reservoir model and a dynamic reservoir model while producing. It would also help understanding fluid movement within the reservoir and estimating vertical and horizontal permeability of the formation. An array of the resisitivity sensors would be able to provide an alert of water coning and water movement in a timely manner.
- Remote sampling Formation sampling tools such as the MDT of Schlumberger need to spend a lot of time pumping out contaminated fluids before acquiring a clean sample from formation. Sampling from the end of a lateral drainhole far exceeding a damaged zone is more beneficial and saves much pump-out time since it is not as badly contaminated as normal sample locations.
- the remote sampling enabled by the present invention allows ssamples from interesting zones identified by LWD measurements to be acquired while drilling.
- In-situ EOR in heavy oil Heavy oil is always difficult to recover productively because of its high viscosity.
- One of the solutions to improve flow of the heavy oil is reduction of the viscosity by heating.
- the present invention permits the possibility of heater installation in the drainholes. Steam injection into the drainholes is an alternative solution.
- An in-situ thermal network by using the drainholes can facilitate the flow of the heavy oil, resulting in a better recovery and production.
- the system according to the invention can overcome or improve problems and difficulties, which are encountered in the conventional drainhole construction in a number of ways, including:
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Claims (22)
- Système de forage pour forer un trou de forage latéral à partir d'un trou de forage principal, comprenant :a) un conduit tubulaire à travers lequel un fluide peut être pompé ; etb) un ensemble de forage raccordé au conduit tubulaire afin de recevoir le fluide pompé à travers ce dernier, l'ensemble de forage comprenant :i) une unité de conversion de puissance (16) à travers laquelle le fluide s'écoule et qui fonctionne pour fournir une puissance de fond de trou ;ii) une unité de forage (26) comprenant un appareil de forage alimenté par la sortie de l'unité de conversion de puissance et fonctionnel pour forer un trou de forage latéral dans la formation entourant le trou de forage principal, et un liner pour stocker un ou plusieurs liner pour l'installation dans le trou de forage latéral ; etiii) une unité d'ancrage fonctionnelle pour ancrer l'ensemble de forage dans le trou de forage principal lorsque l'unité de forage fonctionne pour forer le trou de forage latéral ;
le système étant caractérisé en ce qu'il comprend en outre :iv) une unité de navigation (20) ayant une pluralité de capteurs pour permettre à l'ensemble de forage de naviguer jusqu'à une profondeur et dans une orientation souhaitées,
dans lequel le système de forage comprend également des moyens pour sceller le liner (62) à un tubage (14) dans le trou de forage principal après déploiement ;
lesdits moyens pour sceller le liner au tubage comprenant une pièce d'entonnoir (60) qui est forcée en contact avec le liner pour le sceller au tubage. - Système de forage selon la revendication 1, dans lequel le conduit tubulaire comprend un train de tige de forage ou un tubage enroulé.
- Système de forage selon la revendication 1, dans lequel l'unité de conversion de puissance fonctionne pour convertir l'écoulement de fluide provenant du conduit en puissance électrique ou hydraulique.
- Système de forage selon la revendication 1, 2 ou 3, dans lequel l'unité de forage comprend une tête de forage rotative comprenant un trépan et une unité de puissance pour fournir un couple, un poids sur le trépan et/ou le mouvement axial du trépan.
- Système de forage selon la revendication 4, dans lequel l'unité de forage comprend des capteurs pour mesurer un couple, un poids et/ou un déplacement.
- Système de forage selon la revendication 4 ou 5, dans lequel l'unité de forage comprend un poids sur le système de transmission de trépan qui comprend une tige de forage entraînée, une chute de pression de fluide sur le trépan ou un agencement de jet de fluide.
- Système de forage selon la revendication 4 ou 5, dans lequel l'unité de forage comprend un système de transfert de couple comprenant une turbine à transmission hydraulique pour faire tourner le trépan.
- Système de forage selon l'une quelconque des revendications 1 à 3, dans lequel l'appareil de forage comprend une unité de forage à jet d'eau abrasif, une unité de forage au marteau perforateur, une unité de forage aux ultrasons rotative ou une unité de forage au laser.
- Système de forage selon l'une quelconque des revendications précédentes, dans lequel l'unité de forage comprend un train de tige de forage stocké à l'intérieur de l'unité de forage et pouvant être avancé par rapport à l'unité de forage au fur et à mesure que le forage du trou de forage latéral progresse.
- Système de forage selon la revendication 9, dans lequel le train de tige de forage comprend également le liner.
- Système de forage selon la revendication 9 ou 10, dans lequel le train de tige de forage est formé à partir d'au moins un élément flexible.
- Système de forage selon la revendication 9 ou 10, dans lequel le train de tige de forage est stocké sous une forme segmentée dans l'unité de forage qui est opérationnelle pour assembler les segments de train de tige de forage bout à bout afin de former le train de tige de forage.
- Système de forage selon l'une quelconque des revendications précédentes, dans lequel l'unité de forage comprend un premier sous-système de forage pour forer à travers le tubage entourant le trou de forage principal ; et un second sous-système de forage pour forer dans la formation entourant le trou de forage principal afin de former un trou de forage latéral.
- Système de forage selon l'une quelconque des revendications 1 à 9, dans lequel l'unité de liner est séparée de l'appareil de forage et comprend un liner séparé qui peut être installé dans le trou de forage latéral.
- Système de forage selon la revendication 14, dans lequel le liner est formé à partir d'au moins un élément flexible.
- Système de forage selon la revendication 14, dans lequel le liner est stocké sous une forme segmentée dans l'unité de forage qui est fonctionnelle pour assembler les segments de liner bout à bout afin de former le liner.
- Système de forage selon l'une quelconque des revendications précédentes, comprenant en outre une unité de télémétrie.
- Système de forage selon la revendication 17, dans lequel l'unité de télémétrie étant adaptée de sorte que des données de fond de trou peuvent être transmises à la surface du trou de forage principal et à partir desquelles les commandes provenant de la surface du trou de forage principal peuvent être envoyées à l'ensemble de forage.
- Système de forage selon l'une quelconque des revendications précédentes, dans lequel l'unité de navigation comprenant un magnétomètre, un inclinomètre, un capteur gyroscopique et/ou un localisateur de collier de tubage.
- Procédé pour forer un trou de forage latéral à partir d'un trou de forage principal à l'aide d'un système de forage selon l'une quelconque des revendications précédentes, comprenant les étapes suivantes :positionner l'ensemble de forage dans le trou de forage principal à un emplacement d'intérêt en utilisant un transport tubulaire ;ancrer l'ensemble de forage dans le trou de forage principal à l'aide de l'unité d'ancrage ;actionner l'unité de forage pour forer un trou de forage latéral à partir du trou de forage principal ;récupérer l'unité de forage du trou de forage latéral ;déployer un liner (62) dans le trou de forage latéral ;sceller le liner sur un tubage (14) dans le trou de forage principal ; etlibérer l'unité d'ancrage ; et déplacer l'ensemble de forage vers un autre emplacement ;caractérisé en ce que l'étape consistant à sceller le liner (62) sur le tubage (14) dans le trou de forage principal comprend l'étape consistant à forcer une pièce d'entonnoir (60) en contact avec le liner (62) et le tubage (14).
- Procédé selon la revendication 20, pour améliorer la production d'un puits de production existant.
- Procédé selon la revendication 20, pour prendre in situ des mesures et/ou des échantillons des formations entourant le trou de forage principal.
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
EP07122050.3A EP2065553B1 (fr) | 2007-11-30 | 2007-11-30 | Système et procédé pour forer des trous de forage latéraux |
PCT/EP2008/010153 WO2009068316A1 (fr) | 2007-11-30 | 2008-11-27 | Système et procédé pour forer des puits de forage latéraux |
US12/745,633 US8813844B2 (en) | 2007-11-30 | 2008-11-27 | System and method for drilling lateral boreholes |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
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EP07122050.3A EP2065553B1 (fr) | 2007-11-30 | 2007-11-30 | Système et procédé pour forer des trous de forage latéraux |
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EP2065553A1 EP2065553A1 (fr) | 2009-06-03 |
EP2065553B1 true EP2065553B1 (fr) | 2013-12-25 |
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EP07122050.3A Not-in-force EP2065553B1 (fr) | 2007-11-30 | 2007-11-30 | Système et procédé pour forer des trous de forage latéraux |
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US (1) | US8813844B2 (fr) |
EP (1) | EP2065553B1 (fr) |
WO (1) | WO2009068316A1 (fr) |
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US20110278070A1 (en) | 2011-11-17 |
WO2009068316A1 (fr) | 2009-06-04 |
EP2065553A1 (fr) | 2009-06-03 |
US8813844B2 (en) | 2014-08-26 |
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